Speed control baffle for use in a hydraulic-rotary drilling system

ABSTRACT

A baffle device for use in a drilling sub assembly, the baffle device including an upper chamber for receiving a drilling fluid, the upper chamber having a window through which the drilling fluid exits the upper chamber, the window being in fluid communication with a fluid channel forming a groove on an outer surface of the baffle, the fluid channel having an exit though which the drilling fluid exits the baffle. In general, the exit of the fluid channel is aligned with a downstream turbine unit, such that the turbine unit is rotated by the drilling fluid exiting the baffle. The present invention further includes various modifications to control the velocity at which the drilling fluid exits the baffle.

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention relates to a speed control baffle system for use in driving a hydraulic drilling turbine component of a hydraulic-rotary drilling assembly. Specifically, the present invention relates to a baffle component having features to selectively control the interaction between a drilling fluid and a drilling turbine component of a well drilling assembly. The present invention further provides a baffle component having features to control drilling fluid debris with respect to size and passage through the well drilling assembly.

2. Background and Related Art

As the world becomes increasingly populated and developed, greater demands are made on the world's supply of natural resources. For example, as technology becomes increasingly accessible and affordable to third-world countries, demands for ground water, natural gas, and petroleum also increase. As a result, greater efforts have been required to recover these natural resources to meet the growing demands of the world's population. To address these challenges, the service industry must develop new technology while improving existing products to provide economical solutions to efficiently tap deep reservoirs of natural resources.

Hydraulic drilling is the process of using turbines to rotate a drill bit. As a drilling fluid is passed over the turbine, the turbine is rotated thereby causing the drill bit to rotate. Typically, a drilling fluid is delivered to the turbine via a string of drill pipes extending from the surface to the turbine. There are many types of drilling fluids including air, air and water, air and polymer, water, water-based mud, oil based mud, and synthetic-based fluid. On a drilling rig, drilling fluid (sometimes referred to as mud) is pumped from mud pits through the drill string where it sprays out of nozzles on the drill bit, cleaning and cooling the drill bit in the process. The mud then carries the crushed or cut rock up the annular space between the drill string and the sides of the hole being drilled. These cuttings are then driven up through the surface case where they emerge back at the surface.

The rate of rotation for the drill bit is commonly controlled by incorporating reducer gears between the turbine and the drill bit. In this way, one can select the speed of the bit by selecting an appropriate gear ratio for a given application. However, several difficulties exist with this method of speed control.

For example, reducer gears are commonly exposed to sediments and other debris found in the drilling fluid. Debris within the drilling fluid can become lodged within the reducer gears causing jams and other malfunctions that must be cleared. The process of clearing these jams are time consuming, expensive and potentially damaging to the drilling equipment. Furthermore, in the event that the drill bit becomes jammed while cutting the rock, the inclusion of reducer gears prevents the drill bit from spinning freely in a direction opposite to the jam. Accordingly, the process of undoing the jam results in downtime and may result in damage to the drill bit and other components of the drilling string.

Thus, while techniques currently exist for hydraulic drilling applications, challenges still exist with such techniques. Accordingly, it would be an improvement in the art to augment or even replace current techniques with other techniques.

BRIEF SUMMARY OF THE INVENTION

The present invention relates to a speed control baffle system for use in driving a hydraulic drilling turbine component of a hydraulic-rotary drilling assembly. Specifically, the present invention relates to a baffle component having features to selectively control the interaction between a drilling fluid and a drilling turbine component of a well drilling assembly. The present invention further provides a baffle component having features to control drilling fluid debris with respect to size and passage through the well drilling assembly.

In some implementations of the present invention, a baffle system is provided as a means of directing a supply of drilling fluid to interact with a turbine unit of a drilling sub assembly. The baffle system generally includes a plug having an upper chamber for sorting and degrading debris present within the drilling fluid. The upper chamber includes a plurality of windows that are in fluid communication with fluid channels forming grooves on an outer surface of the baffle.

The drilling fluid is delivered to the upper chamber whereafter the fluid exits the windows and flows through the fluid channels. In some implementations of the present invention, an exit of each fluid channel is positioned such that the drilling fluid exits the fluid channel to directly contact the blades of the turbine unit. The drilling fluid exits with a velocity sufficient to rotate the turbine unit at a desired rate. The baffle system further includes a variety of adjustable features whereby a user may modify the features to adjust the velocity at which the drilling fluid exits the baffle.

In some implementations of the present invention, the length, width, angle and shape of the fluid channel is altered to affect the velocity at which the drilling fluid exits the baffle. In other implementations, the number of windows and correlating fluid channels is adjusted to increase or decrease the velocity of the drilling fluid. Still, in other implementations a single fluid channel is branched such that a single window supplies drilling fluid to a plurality of fluid channels. Baffles of the present invention may further include a one, two, three or four fluid channels. In some implementations, the baffle system includes greater than four fluid channels.

An upper chamber of the baffle may include a sloped surface such that the upper chamber includes varying depths. In particular, the upper chamber includes a deep section that experiences aberrant currents that churn and otherwise mix the drilling fluid. The deep section of the upper chamber further collects large debris within the drilling fluid. These large debris are subsequently subjected to the aberrant currents where they are degraded and broken down into smaller debris that are safe for passage through downstream components. In some implementations, a wire screen mesh is further included in the upper chamber such that the mesh screen prevents large debris from exiting the chamber via the windows.

A modular baffle is further provided wherein the baffle includes an upper section and a lower section. The upper section includes a tubular member having a plurality of windows. The upper section is configured to compatibly seat on the lower section such that the plurality of windows aligns with the fluid channels of the lower section. The fluid channels of the lower section may include any size, shape, configuration and width as determined by the user. Thus, the upper section may be interchangeably used with any lower section having a number of fluid channels equal to the number of window. In this way, the user may combine the upper section with a lower section having a desire fluid channel configuration.

BRIEF DESCRIPTION OF THE DRAWINGS

In order that the manner in which the above-recited and other features and advantages of the invention are obtained will be readily understood, a more particular description of the invention briefly described above will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings. These drawings depict only typical embodiments of the invention and are not therefore to be considered to limit the scope of the invention.

FIG. 1 is a schematic representation of a well drilling rig incorporating a drilling sub assembly in accordance with a representative embodiment of the present invention.

FIG. 2 is a cross-section view of a drilling sub assembly in accordance with a representative embodiment of the present invention.

FIG. 3A is a perspective view of a baffle in accordance with a representative embodiment of the present invention.

FIG. 3B is a perspective view of a wire mesh screen used in combination with a baffle in accordance with a representative embodiment of the present invention

FIG. 3C is a cross-section view of a baffle in accordance with a representative embodiment of the present invention.

FIGS. 3D through 3H are perspective views of baffles having various fluid channel configurations in accordance with representative embodiments of the present invention.

FIGS. 4A through 4D are bottom plan views of a baffle showing various configurations of fluid channels in accordance with representative embodiments of the present invention.

FIG. 5 is an exploded perspective view of a modular baffle system in accordance with a representative embodiment of the present invention.

DETAILED DESCRIPTION OF THE INVENTION

The presently preferred embodiments of the present invention will be best understood by reference to the drawings, wherein like reference numbers indicate identical or functionally similar elements. It will be readily understood that the components of the present invention, as generally described and illustrated in the figures herein, could be arranged and designed in a wide variety of different configurations. Thus, the following more detailed description, as represented in the figures, is not intended to limit the scope of the invention as claimed, but is merely representative of presently preferred embodiments of the invention.

Referring now to FIG. 1, a representative well drilling rig 10 is shown. Drilling rigs can be massive structures housing equipment used to drill water wells, oil wells or natural gas extraction wells. Drilling rigs can also be small enough to be moved manually by one person. In some implementations, drilling rigs can be mobile equipment mounted on trucks, tracks or trailers. In other implementations, drilling rigs include more permanent land or marine-based structures, such as an oil platform.

A drilling rig 10 generally comprises a derrick 12 or other support structure used for lifting and positioning a drilling string 14 and piping 16 above the well bore hole 20. Derrick 12 is further useful in supporting machinery 18 for turning and advancing the drilling string 14 into the hole 20. As the drilling string 14 goes deeper into the underlying soil or rock, new piping 16 is added to the top of the drilling string 14 to keep the connection between the drill bit 50 and the turning machinery 18 intact, and to create a filler to keep the hole 20 from caving in. The piping 16 further provides a conduit whereby drilling fluid 40 is delivered to the drill bit 50. The drilling fluid 40 is pumped 22 through the drilling string 14 via an ingress line 42. The drilling fluid is delivered to the drill bit 50 where the drilling fluid is used to cool the drilling bit 50 and to blow rock debris clear from the drill bit 50 and the bottom of the bore hole 20. The drilling fluid 40 exits the drill bit 50 and then proceeds upward towards the surface on the outside of the piping 16, carrying the debris with it. The drilling fluid 40 and debris then flow through the well head 26 and are delivered to a mud tank 30 via an egress line 44.

The derrick 12 also controls the weight on the drilling bit 50, thereby maintaining the optimum degree of pressure between the drill bit 50 and the rock beneath it. Eventually, lifting equipment 28 is used to lift the entire drilling string 14 complex to prevent too much weight as the well goes deeper.

There are a variety of drilling procedures and methods which can be used to sink a borehole into the ground. Each has its advantages and disadvantages, in terms of the depth to which it can drill, the type of sample returned, the costs involved and the penetration rates achieved. Hydraulic-rotary drilling is a method whereby the flow of a drilling fluid is used to rotate a drill bit within a drill bore hole. For this method of drilling, drilling string 14 is equipped with a drilling sub assembly 100.

Drilling sub assembly 100 generally comprises a variety moving and non-moving parts that are designed to convert the flow of drilling fluid into rotational force to drive the drilling bit 50. For example, some drilling sub assemblies incorporate a turbine whereby the drilling fluid is passed over the turbine to cause the turbine to rotate. Some drilling sub assemblies further provide reducer gears (not shown) to regulate the rotation rate of the drill bit relative to the turbine speed. Thus, piping 16 acts as a stationary conduit to deliver drilling fluid to the various moving parts of drilling sub assembly 100. This configuration largely eliminates torque throughout the drilling string 14 thereby permitting the achievement of deeper drilling depths.

Referring now to FIGS. 1 and 2, a representative drilling sub assembly 100 is shown. One of skill in the art will appreciate that drilling sub assembly 100 is merely a representative embodiment in which to discuss and demonstrate certain features of the present invention, and that the present invention may be equally incorporated into any hydraulic-rotary drilling device. In general, a sub assembly compatible with the present invention is provided as a means for converting the flow of drilling fluid into a rotational force at the drill bit 50. Specifically, the drilling sub assembly 100 utilizes a turbine unit 140 to convert the linear flow of drilling fluid into a rotational force needed to rotate the drill bit 50.

Some embodiments of the drilling sub assembly 100 comprise a modular unit having a plurality of interconnected sections. Each section is configured to work compatibly with the remaining sections to achieve desired working conditions for the drill bit 40. For example, in some embodiments the drilling sub assembly 100 includes an upper component 120, a mid component 130 and a lower component 140. The upper component 20 generally comprises a body casing having a first end 122 for threadedly coupling piping 16. The upper component 120 further comprises a second end 124 for threadedly coupling the mid component 130 or bearing housing of the drilling sub assembly 100.

The bearing housing 30 houses various bearing units 160 to permit free rotation of the lower component 140 or mandrel relative to the stationary drill piping 16, body casing 120 and bearing housing 130. The mandrel 40 comprises a threaded end 142 for coupling the drill bit 50. Thus, the various components 120, 130 and 140 of the drilling sub assembly 100 are configured to direct the flow of drilling fluid to cause rotation of drill bit 50.

With continued reference to FIG. 2, a cross-section view of the drilling sub assembly 100 is shown, as isolated from the piping 16 and drill bit 50. The upper component 120 or body casing generally comprises an elongate tubular member having an internal lumen 126. The internal lumen 126 is generally configured to include various diameters to receive internal components of the sub assembly 100. For example, in some embodiments the internal lumen 126 houses a baffle 150 adjacent to the first end 122 opening. The baffle 150 generally comprises a plug having a fluid channel 152 for directing and focusing the drilling fluid to selectively interact with downstream internal components. The general purpose of the baffle component 150 is to direct the flow of drilling fluid into the remainder of the drilling sub assembly 100. The baffle component 150 of the present invention will be discussed in detail below.

Turbine unit 190 is generally rotatably positioned within body casing 120 and includes a plurality of blades 220. The plurality of blades 220 are generally positioned so as to cause the turbine unit 190 to rotate in a desired direction upon contact with the drilling fluid. In some embodiments, a bearing unit 162 is interposed between the turbine unit 190 and the baffle 150 to permit the turbine unit 190 to rotate freely relative to the fixed position of the baffle 150.

The turbine unit 190 may include any configuration compatible with a given hydraulic-rotary drilling system. In some embodiments, turbine unit 190 comprises a plurality of turbine units. In other embodiments, turbine unit 190 comprises a plurality of concentric turbine units. Still, in other embodiments turbine unit 190 comprises a plurality of turbine units that are configured to rotate in opposite directions or to oscillate between a forward and a reverse direction. One having skill in the art will appreciate that any number of possible variations may be implemented to provide a suitable turbine unit that operates on the base principles set forth herein. Therefore, one of skill in the art will appreciate that turbine unit 190 is only one example of a suitable turbine unit that may be used in combination with baffle 150.

The mid component 130 or bearing housing is provided as a means for housing various bearing units 160 to further permit free rotation of turbine unit 190 relative to the fixed positions of the piping 16, body casing 120, baffle 150 and bearing housing 130. In some embodiments, bearing housing 130 comprises an upper bearing surface 170 to support a bearing unit 160 interposedly positioned between the turbine unit 190 and the bearing housing 130. The bearing housing further comprises a lower bearing surface 172 to support a bearing unit 160 interposedly positioned between the lower component 140 and the bearing housing.

The lower component 140 or mandrel extends upwardly through the bearing housing 130 and is threadedly coupled to the turbine unit 190. As such, rotation of the turbine unit is directly transferred to mandrel 140. A threaded opening 142 of the mandrel 140 is provided to enable direct coupling of a drill bit 50 to the end of the mandrel 140. Thus, rotation of the turbine unit 190 is directly transferred to mandrel 140 which in turn directly rotates drill bit 50.

Referring now to FIG. 3A, a perspective view of the baffle 150 is shown. Baffle 150 is generally configured to compatibly insert within the drilling sub assembly 100. Therefore, in some embodiments baffle 150 comprises a cylindrical shape. However, one having skill in the art will appreciate that baffle 150 may include any shape or profile as required by a given drilling sub assembly design. For example, in some embodiments baffle 150 comprises a generally square shape. In other embodiments, baffle 150 comprises a polygonal shape.

Baffle 150 comprises a first end 154 and a second end 156, as shown in FIG. 3A. The first end 154 comprises an upper chamber 270 for receiving an upstream drilling fluid. The upper chamber 270 is generally cylindrical having a bottom surface 174 that is slanted or oblique relative to the vertical walls 176 of the chamber 270. The upper chamber 270 further includes a plurality of windows 178 in fluid communication with fluid channel 152. Fluid channel 152 generally comprises a groove on the external surface of baffle 150, wherein the fluid channel 152 directs flow of the drilling fluid between the baffle 150 and the inner surface of the body casing 120. Thus, the out diameter of baffle 150 is selected to minimize any tolerance between the baffle 150 and the inner surface of the body casing 20.

In some embodiments, fluid channel 152 comprises a shape or configuration to change or direct the flow of drilling fluid as it leaves the fluid channel 152. For example, the fluid channel 152 of FIG. 3A has a first portion 260 and a second portion 262. First portion 260 is generally vertically oriented. However, second portion 262 is generally angled thereby redirecting the flow of the drilling fluid. The combined features of first and second portion 60 and 62 thereby provide means for directing the drilling fluid to selectively interact with a downstream internal component. One of skill in the art will appreciate that the specific structure, design and layout of fluid channel 152 may be highly modified to achieve a specific function for the drilling fluid. Examples of such modifications will be discussed in detail below.

The slanted configuration of bottom surface 174 naturally provides the upper chamber 270 with varying depths. A portion of the upper chamber 270 having the greatest depth experiences aberrant currents as the drilling fluid flows down the slanted surface into the vertical interior wall 180. In particular, drilling fluid within this nadir of the upper chamber 270 experiences eddies that churn and otherwise mix the drilling fluid. In general, the positions of window 178 are selected so as prevent placement of a window at the lowest or nadir portion of upper chamber 270. As such, debris is permitted to freely churn within this portion of the upper chamber 270 without being lodged in a window 178.

In some embodiments, unwanted debris within the drilling fluid gravitate to the nadir portion of the upper chamber 270 where they are subjected to aberrant currents that reduce the size and/or trap the unwanted debris. Eventually, the unwanted debris is sufficiently reduced in size and thereby released from the aberrant current and permitted to exit the upper chamber 270 via the window 178.

In some embodiments, the dimensions of window 178 are selected to prevent passage of unwanted debris having a size sufficient to harm or jam downstream internal components. For example, in some embodiments the area of window 178 is increased to allow passage of larger debris to flow into fluid channel 152. In other embodiments, the area of window 178 is decreased to prevent passage of larger debris to flow into fluid channel 152. Accordingly, the combined features of the slanted bottom surface 174 and the plurality of windows 178 prevents jams and other malfunctions due to debris in the drilling fluid.

Still further, in some embodiments a wire mesh screen 288 is positioned within upper chamber 270 so as to partially block windows 178, as shown in FIG. 3B. The wire mesh screen 288 is generally configured to permit passage of debris that will not adversely affect the downstream components of the drilling sub assembly 100. Implementation of a wire mesh screen 288 enables the user to increase the area of windows 178 to allow increased fluid flow without permitting passage of large debris found in the drilling fluid.

In some embodiments, the second end 156 of baffle 150 comprises a lower chamber 272 for rotatably receiving a downstream internal component, as shown in FIG. 3C. In particular, lower chamber 272 may comprise a recess for compatibly and rotatably receiving a turbine unit 190, as shown in FIG. 2. In general, the second end 156 of baffle 150 is positioned such that drilling fluid is directed to contact the turbine unit 190 of the system 10 as the drilling fluid exits the fluid channel 152. Accordingly, one of skill in the art will appreciate that the second end 156 of baffle 150 may be modified in any number of ways so as to be compatible with any desired hydraulic-rotary drilling system.

For example, in some embodiments the second portion 262 of the fluid channel 152 is positioned at an angle 66 to achieve a desired contact between the drilling fluid and the plurality of blades 220. In some embodiments angle 66 is selected to be 90° to the plurality of blades 220. In other embodiments, angle 66 is selected to be less than or greater than 90° to the plurality of blades 220.

Referring now to FIGS. 3D through 3H, baffle 150 is shown having various modified fluid channels 150. For example, FIG. 3D demonstrates a linear fluid channel 252, wherein window 178 and fluid channel 252 are both vertically oriented. FIG. 3E shows a curved or swept fluid channel 352, wherein the window 178 is vertically oriented and the remainder of the fluid channel 352 is curved to achieve a final desired angle 66 at channel exit 380. FIG. 3F demonstrates a slanted fluid channel 452, wherein window 178 and the remainder of the fluid channel 452 are both slanted at a desired angle 66.

In some embodiments, the dimensions of the fluid channel are altered or structured to increase or decrease the velocity of the drilling fluid as is passed through the fluid channel. Thus, one may control the rotational speed of the turbine unit by simply modifying the dimensions of the fluid channel. For example, as shown in FIG. 3G fluid channel 552 is inwardly tapered such that the width of the channel exit 580 is narrower than the width of window 178. Thus, the velocity of the drilling fluid increases as the drilling fluid flows through fluid channel 552. In other embodiments (not shown), fluid channel 552 is outwardly tapered such that the width of channel exit 580 is wider than the width of window 178. Accordingly, the wider channel exit 580 (not shown) acts as a diffuser to reduce the velocity and fluid pressure of the drilling fluid as is passed through fluid channel 552.

In addition to modifying the dimensions of the fluid channel, one may control the rotational speed of the turbine unit by modifying the angle 66 at which the drilling fluid exits the fluid channel to interact with the blades 220 of the turbine unit 190. Non-limiting examples of such modification are shown in FIGS. 3A through 3G, above.

Referring now to FIG. 3H, fluid channel 652 is branched to include a plurality of channel 680, 682 and 684, each channel having an exit angle 66, 68 and 70, respectively. In some embodiments a single window 178 may provide drilling fluid to a plurality of channels and channel exits. Channels 680, 682 and 684 may include varying lengths or may be of equal lengths. Channels 680, 682 and 684 may further include tapered or uniform widths. In some embodiments, angles 66, 68 and 70 are substantially equal. In other embodiments, angles 66, 68 and 70 are different. One having skill in the art will appreciate that fluid pressure and velocity within channels 680, 682 and 684 will vary based upon their individual and collective positions, widths and lengths. One having skill in the art will further appreciate that modifying angles 66, 68 and 70 will affect the overall rotational velocity of the turbine unit. Thus, providing branched channels 680, 682 and 684 is an effective method for controlling, i.e. increasing or decreasing the rotational velocity of the turbine unit 190 and those additional component coupled thereto.

Referring now to FIGS. 4A through 4B, various bottom plan views of baffle 150 are shown. Baffle 150 may be modified to include any number of fluid channels 152. For example, in some embodiments baffle 150 is modified to include one, two, three or four fluid channels 152. In other embodiments, baffle 150 comprises more than four fluid channels 152.

In some embodiments, baffle 250 is a modular unit, as shown in FIG. 5. In this embodiment, baffle 250 comprises an upper tubular portion 264 having a plurality of windows 178. Windows 178 are positioned so as to line up exactly with fluid channels 280 of the lower base portion 266. Lower base portion 266 is generally solid and includes fluid channels 280 each having a desired shape, angle and width. A bottom surface 278 of upper tubular portion 264 is angled so as to seat directly on lower portion 266. In some embodiments, an o-ring or other sealing member (not shown) is interposed between the upper and lower portions 264 and 266 to prevent leakage of drilling fluid at bottom surface 278.

The modular baffle 250 enables use of the upper tubular portion 264 with any lower portion 266 having a number of fluid channels equal to the number of windows 178. Thus, a single upper portion 264 may be interchangeably used with any number of lower portions 266 having any variety fluid channel configurations. Therefore, a user may pick and choose a configuration that is compatible with the needs of a specific drilling operation.

Referring generally to the various embodiments discussed above, of particular interest to the present invention is the lack of gears or other means for controlling the direction and/or speed of a turbine unit of a hydraulic-rotary drilling system. In some embodiments of the present invention, the rate of rotation for the turbine unit is directly proportional to the flow rate of drilling fluid through the drilling sub assembly 100. Thus, the speed of the turbine unit may be variably adjusted by increasing or decreasing the flow rate of the drilling fluid. In some embodiments, the flow rate of the drilling fluid is controlled by adjusting a pump or flow regulator associated with the drilling fluid. In other embodiments, the flow rate of the drilling fluid is adjusted by modifying the various discussed features of baffle 150.

The use of a baffle in accordance with the teachings of the present invention allows for speed control of a turbine unit and drill bit without the use of gears. This feature eliminates the possibility of damage to the drilling sub assembly 100 in due to internal or external jams. For example, should the turbine unit jam due to the presence of debris within the drilling fluid, the turbine unit would simply cease to rotate. The drilling fluid would continue to bypass the turbine unit until either the debris was dislodged by the drilling fluid, or the jam was physically removed. Similarly, in the event of the drill bit becoming jammed, the turbine unit, the mandrel and the drill bit would simply cease rotating. Accordingly, an operator would back the drill bit away from the jam thereby permitting the turbine unit, the mandrel and the drill bit to recover their rotational velocity. The operator would then resume the drilling operation.

The present invention may be embodied in other specific forms without departing from its structures, methods, or other essential characteristics as broadly described herein and claimed hereinafter. Thus, the described embodiments are to be considered in all respects only as illustrative, and not restrictive. The scope of the invention is, therefore, indicated by the appended claims, rather than by the foregoing description. All changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope. 

1. A baffle device for use in a drilling sub assembly, the baffle device comprising: an outer surface having a profile selectively shaped to compatibly insert within an outer casing of a drilling sub assembly; a first end having an upper chamber for receiving an upstream drilling fluid, a perimeter of the upper chamber being defined by a vertical wall, the upper chamber further having a bottom surface that is oblique to the vertical wall; a window formed in the vertical wall, the window providing an outlet to the upper chamber; a fluid channel forming a groove on the outer surface of the device, the fluid channel having a first section forming a portion of the window, the first end section being in fluid communication with the upper chamber, the fluid channel further having a second section extending to a second end of the device; and a fluid channel exit forming an outlet to the fluid channel, the fluid channel exit being positioned approximate to the second end of the device, wherein a drilling fluid exits the upper chamber through the window and flows through the fluid channel to exit the device through the fluid channel exit.
 2. The device of claim 1, further comprising a lower chamber forming a portion of the second end of the device, the lower chamber compatibly and rotatably receiving a turbine unit of the drilling sub assembly.
 3. The device of claim 1, wherein the fluid channel comprises a plurality of fluid channels.
 4. The device of claim 1, wherein the window comprises a plurality of windows.
 5. The device of claim 1, wherein the window comprises dimensions to prevent passage of a debris present within the drilling fluid.
 6. The device of claim 1, further comprising a wire mesh screen inserted within the upper chamber to cover the window and thereby prevent passage of a debris through the window.
 7. The device of claim 1, wherein the upper chamber comprises a nadir at which the drilling fluid experiences aberrant currents.
 8. The device of claim 1, wherein the fluid channel is linear.
 9. The device of claim 1, wherein the fluid channel is curved.
 10. The device of claim 1, wherein the fluid channel is branched.
 11. The device of claim 1, wherein the fluid channel is tapered.
 12. The device of claim 1, wherein the fluid channel exit is angled such that the drilling fluid contacts a downstream turbine unit at an angle from approximately 1° to about 90°.
 13. A method for controlling the rotational speed of a drill bit used in a hydraulic-rotary drilling system, the method comprising: providing a baffle having an upper chamber for receiving a drilling fluid, the upper chamber having a window through which the drilling fluid exits the upper chamber, the window being in fluid communication with a fluid channel forming a groove on an outer surface of the baffle, the fluid channel having an exit through which the drilling fluid exits the baffle; positioning the baffle upstream from a turbine unit such that the exit of the baffle is aligned with a blade of the turbine unit; and angling a portion of the fluid channel such that the drilling fluid exits the baffle to contact the blade of the turbine unit at an angle from approximately 1° to about 90°.
 14. The method of claim 13, further comprising tapering the fluid channel to modify the velocity at which the drilling fluid flows through the fluid channel.
 15. The method of claim 13, further comprising branching the fluid channel.
 16. The method of claim 13, wherein the window comprises a plurality of windows.
 17. The method of claim 13, wherein the fluid channel comprises a plurality of fluid channels.
 18. A modular baffle system, comprising: a tubular chamber member having an upper rim surface, a bottom rim surface, and a wall surface therebetween, the bottom rim surface being in a first plane that is generally oblique to the wall surface; a window forming a notch in the bottom rim surface and the wall surface; and a base portion having a top surface to support the bottom rim surface of the tubular chamber, the base portion further having a fluid channel forming a groove on an outer surface of the base portion, the top surface being in a second plane that is equal to the first plane, wherein the window and the fluid channel are aligned by seating the tubular chamber member on the base portion in the first plane.
 19. The system of claim 18, further comprising a plurality of fluid channels.
 20. The system of claim 18, further comprising a plurality of windows. 